Disclosed is an actuator capable of imparting a linear, rotary, or combined roto-linear force. In one embodiment, the actuator has a rotor and a stator, each having helical grooves with a thrust ball occupying the grooves. A nose piece is situated at the end of the actuator and can be attached to other equipment. The actuator is electrically controlled and can be used in applications requiring high forces or other specialized environments.

Disclosed is an actuator capable of imparting a linear, rotary, or combined roto-linear force. In one embodiment, the actuator has a rotor and a stator, each having helical grooves with a thrust ball occupying the grooves. A nose piece is situated at the end of the actuator and can be attached to other equipment. The actuator is electrically controlled and can be used in applications requiring high forces or other specialized environments.

The present invention provides a rotary guiding tool, comprising: a power unit having an output shaft capable of outputting a torque and an offset driving portion capable of outputting a radial force and/or an axial force; a transmission shaft connected with the output shaft; a support shaft connected with the transmission shaft through a rotation structure, wherein a rotation axis of the rotation structure is perpendicular to an axis of the output shaft, the support shaft has an inner wall defining an accommodating cavity and a forward end and a rearward end formed at both ends of the accommodating cavity, a rotation center of the rotation structure is located in the accommodating cavity, and the rearward end of the support shaft is capable of being driven by the radial force output by the offset driving portion; and a drill bit having a drill bit tail end, wherein the drill bit and the forward end of the support shaft are connected to the drill bit tail end. According to the present invention, the rotary guiding tool may improve the whipstocking ability of the drilling tool, and reduce the energy consumption of driving the drilling tool.

A method for operating a well tractor is presented. The method involves running a well tractor coupled to a wireline into a wellbore and supplying an amount of electric power to the well tractor to operate the well tractor at a first speed to urge the wireline through the wellbore at a first force. A variable gear ratio transmission of the well tractor is adjusted and an amount of electric power is supplied to the well tractor to operate the well tractor at a second speed different than the first speed to urge the wireline through the wellbore at a second force different than the first force based on adjusting the variable gear ratio transmission.

A downhole rotary seal assembly is provided that includes a primary rotary seal, a barrier seal, and a seal carrier. The seal carrier includes an inner surface, an outer surface, and a first groove dimensioned to receive the primary rotary seal at the inner surface. The seal carrier also includes a second groove dimensioned to receive the barrier seal at the inner surface. An aperture is defined on the inner surface between the first groove and the second groove. A relief port is positioned between the first groove and the second groove, the relief port being positioned to fluidly couple the aperture and the outer surface. A valve provided in the relief port. The valve includes a check valve having a predefined crack pressure.

This disclosure provides a downhole drilling tool that has a deep-reading logging tool, a near-bit resistivity tool, and a gamma ray detector. Formation information logged using the deep-reading logging tool is used to build a preliminary stratigraphic model with a relatively low resolution. The preliminary stratigraphic model is further refined using data logged using the near-bit resistivity tool and/or the gamma ray detector to obtain a refined stratigraphic model with a higher resolution. The model is used to guide geosteering to achieve better well placement and trajectory control.

Systems are provided comprising at least one driving cylinder comprising a driving chamber and a driving piston within the driving chamber. The driving piston separates the driving chamber into a driving fluid zone for receiving a driving fluid and a buffer zone for receiving a buffer fluid. The driving piston is movable in the driving chamber by the driving fluid. The systems may also comprise a driven cylinder comprising a driven chamber and a driven piston moveable in the driven chamber. The driven piston is connected to and driven by the driving piston to move within the driven chamber. The driven chamber comprises an input port configured to receive a driven fluid at a first, lower pressure into the driven chamber and an output port configured to expel the driven fluid at a second, higher pressure from the driven chamber when the driven fluid is pressurized by the driven piston. The buffer fluid is different from the driving fluid and the driven fluid, and the buffer fluid in the buffer zone separates the driving fluid from the driven fluid.

This disclosure provides a downhole drilling system, which comprises a downhole motor, a universal-joint assembly comprising an upper universal joint and a lower universal and a connecting rod connecting the upper universal joint and the lower universal joint, and a measurement sub. The measurement sub is disposed about the connecting rod and the connecting rod extends through the measurement sub in a longitudinal direction thereof.

An example downhole motor may include a first housing and a second housing with first and second portions characterized by non-parallel longitudinal axes. The second housing may be rotatably coupled to the first housing, and the first portion of the second housing may be arranged in a fixed, non-parallel longitudinal orientation with the first housing. A drive shaft may be at least partially within the first housing, and the motor may further comprise a selectively engageable torque coupling between the drive shaft and the second housing, positioned within the first housing.

A system includes at least one processing unit and a bottomhole assembly (BHA) that includes or communicates with the at least one processing unit. The BHA includes at least one drilling component and at least one acoustic transducer to convert drilling noise into one or more electrical signals. The at least one processing unit analyzes the one or more electrical signals or related data to categorize different components of the drilling noise as rock contact noise and mechanical noise. The at least one processing unit derives a data log, a plan, or a control signal based on the categorized drilling noise components.